Well tools

ABSTRACT

A pluggable well packer and operator means therefor runnable on a pipe string into a well and fluid pressure settable without manipulation of the pipe string to seal off and production test a well formation, and operable for cementing off said formation and plugging said well; said operator means being thereafter removable with said pipe string. The method of treating a well by means of the foregoing is also set forth.

UnitedStates Patent References Cited UNITED STATES PATENTS 2,263,56611/1941 Boynton 166/150 2,630,865 3/1953 Baker 166/120 3,062,291 11/1962Brown 166/120 3,306,359 2/1967 Edwards, .11. 166/120 3,318,384 5/1967Brown 166/120 3,387,660 6/1968 Berryman. 166/181 3,412,799 11/1968 Ellis166/120 3,420,304 1/1969 Kilgore 166/181 Primary Examiner-James A.Leppink Attorney-E. Hastings Ackley ABSTRACT: A pluggable well packerand operator means therefor runnable on a pipe string into a well andfluid pressure settable without manipulation of the pipe string to sealoff and production test a well formation, and operable for cementing offsaid formation andplugging said well; said operator means beingthereafter removable with said pipe string. The method of treating awell by means. of the foregoing is also set forth.

PATENTEU JAN 19 I97! SHEET 1 BF 7 m wl w. *3 mm m u m 8 8 W mm on Nm- Nvm 3 mm M, on N mm mm 3 mm) on on No MN 94) an n m? mr or 2% Q nu. I4 mM. r 5 21 F N1 n? 5 m i f m w @E m 01 N- OE z QT. -rm w C mN MN QINVENTOR HARRY E. SCHWEG MAN ATTORNEY PATENTED JAN 1 9 I97l' SHEET 2 OFI INVENTOR HARRY E. fSCHWEGMAN ATTORNEY PATENTEU JAN 1 9 l9?! SHEET 3 UP7 FIG-l0 INVENTOR HARRY E. SCHWEGMAN ATTORNEYS PATENTEOJAMQIQYI 3556220saw u or 7 HG INVENTOR HARRY E.. SCHWEGMAN ATTORN EY PATENTEDJANISISYI8556220 sum 50F 7 INVENTOR HARRY E.. SCHWEG MAN FIG ATTORNEY PATENTEDJAM9 19m FIG: I5.

SHEET 8 BF 7 INVENTOR HARRY E. SC HWE GM AN ATTORNEY PATENTED m1 9 m1 3Q 5 5s; 22 0 Y SHEEIIUF? INVENTOR HARRY ESCHWEGMAN ATTORNEY WELL TOOLSOne object of this invention is to provide an improved tool for use inthe production testing of wells, particularly submarine wells.

An important object of the invention it to is to provide a productiontesting tool which is lowerable into a well on a pipe string, which maybe set, without manipulating said pipe string. by fluid pressure appliedthrough said pipe string.

A further object is to provide a tool of the type described which can beconverted to a bridge plug subsequent to the production testing phase ofthe operation.

A still further object is to provide a tool of the character describedwhich includes a running tool having flow port means openable forkilling the well after the production test, and reclosable to permit thepumping of cement through the tool and intothe formation below the toolfor the plugging operation.

A yet further object is to provide a tool of the character describedwhich is operable to permit the removal of all excess cement above thetool by reverse circulation subsequent to the cementing operation.

Another object of this invention is to provide a well tool for use inproduction testing and cementing of a well, particularly a submarinewell, including a running tool having holddown means expandable by thefluid pressure in the flow passage of said tool, said holddown meansbeing engageable with the interior wall of the casing so that thepressure in the well bore which tends to displace the production toolupwardly will expand the holddown means into engagement with the wellcasing to prevent such upward displacement, during all phases ofoperation of the tool.

Another object is to provide such a tool which includes a well packerportion having lateral ports in the wall thereof below the packer sealelements and a plug which is installable in the packer bore below saidlateral ports, said lateral ports being closable after said plug isinstalled so that back flow of fluids through the tool will beprevented. An important object of the invention is to provide a welltool and operating means therefor which can be used for the productiontesting and subsequent plugging of a well, by means of which bothoperations may be performed during a single trip of the pipe by means ofwhich the tool is run and operated.

Another important object is to provide a system of for and method oftreating a well having a casing and a wellhead, wherein a well tool andoperator means are connected to a well flow conductor and loweredthereby to a desired location in said casing and said flow conductor isthen suspended at the wellhead, said well tool and operator means beingactuated thereafter by fluid pressure applied through said flowconductor for sealing off and production testing a well formation, andoperable thereafter for cementing off said flow conductor aredisconnectable from said well tool for removal from said well casing,leaving said well tool in place.

A particular object of the invention is toprovide a system for and amethod of treating a well having a casing and a well head, wherein awell tool and operator means are connected to a well flow conductor andlowered thereby to a desired location in said casing and said flowconductor is then suspended at the wellhead, said well tool and operatormeans being actuated thereafter by fluid pressure applied through saidflow conductor for sealing off and production testing a well formation,and operable thereafter for cementing off said well formation, said welltool and operator means being provided with means for establishing flowpaths for the circulation of fluids thru through flow conductor and saidcasing subsequent to said production testing and after said cementingoperations, and wherein said operator means and said flow conductor aredisconnectable from said well'tool for removal from said well casing,leaving said well tool in place.

Additional objects and advantages of the invention will be readilyapparent from the reading of the following description of devicesconstructed in accordance with the invention, and reference to theaccompanying drawings thereof, wherein:

FIG. 1 is a fragmentary schematical. view showing the well tool andoperator means disposed in a submarine well ready for operation;

FIG. 2 is a fragmentary schematical view similar to FIG. 1 showing thewell tool being actuated to position sealing off the well formation; 7

FIG. 3 is a view similar to FIG. 2 showing upper lateral flow portsbeing opened preparatory to killing the well;

FIG. 4 is a vie similar to FIG. 3 shown showing the upper lateral portreclosed by a straddle member and plug assembly;

FIG. 5 is a view similar to FIG. 4 showing the plug in position closingthe lower end of the packer bore with lower lateral flow ports open;

FIG. 6 is a view similar to FIG. 5 showing the operator meansdisconnected from the well tool and the lower lateral flow ports andpacker bore closed to plug the well;

FIGS. 7, 8, 9, l0 and 11, taken together, form an enlarged view, partlyin elevation and partly in section, showing the details of constructionof the well tool and operator means in running-in condition;

FIGS. 12, 13 and 14, taken together, form an enlarged view, partly inelevation and partly in section, of the lower portion of the operatormeans and the well tool showing the well tool showing the well toolactuated to sealing position;

FIG. 15 is an enlarged view, partly in elevation and partly in section,showing the straddle member and plug assembly closing the upper lateralflow ports of the operator means;

FIG. 16 is an enlarged view, partly in elevation and partly in section,of the lower portion of the well tool showing the plug closing the boreof said well tool before the lower lateral flow ports are closed;

FIG. 17 is a fragmentary view, partly in elevation and partly insection, of the upper portion of the well tool showing the connectionbetween the operator means and the well tool released; and

FIG. 18 is a fragmentary view similar to FIGS. 14 and 16 showing thelower lateral flow ports closed and the lower end portion of theoperator means being withdrawn from the well tool.

In the drawings, FIG. 1, a submarine well installation 20 is shownschematically, in which the well is drilled into the earth at the bottomof the body of water. The well installation includes a casing Cpenetrating the earth producing formation F and having a wellhead orhanger assembly 1-1 at the upper end of the casing. The hanger assemblyincludes a seat S and a blowout preventer B, and may be similar to thesubmarine wellhead installation illustrated and described in the U.S.Pat. No. 3,411,576, to Donald F. Taylor, Jr. A drilling platform orvessel P is shown as floating on the surface of the water and flexibleflow conduits T and L are illustrated as extending downwardly from thedrilling vessel to he wellhead H, the line T being connected to theupper end of the tubing string or production tubing 21 extendingdownwardly in the well casing and supported by a hanger 22 on the seat Sin the wellhead. The rams 23 of the blowout preventer are shown asclosed around the flow conductor T, and a valve 24, which may be anautomatic or surface controlled safety valve of the type generally shownin the aforesaid U.S. Pat. No. 3,41 1,576, may be provided in the flowconductor T to permit disconnection of the flow conductor above thewellhead in the event of storm or other threat of damage. Similarly, theflow conduit L is connected to the side port, flow wing or outlet 25 ofthe wellhead H, and a valve 26 is connected in the flow conductor forcontrolling flow through said lateral flow port.

Obviously, to both the safety valve 24 in the tubing string 21 and thelateral flow wing valve 26 communicating with the casing annulus may beremotely controlled or may be automatically operable.

The well system and method of this comprehends the use of a wellapparatus including a well packer and plug tool 30 and an operator andrunning tool 31 releasably connected together in longitudinal alignmentand carried by the lower end of the well production tubing string 21 asshown in FIG. 1. The packer and plug tool includes a mandrel or body 33having a seal element 35 and upper and lower gripping means or slipassembles 36 and 37. respectively, on said body. The operator andrunning tool 31 includes an elongate body or mandrel 38 which isconnected at its upper end to the lower end of the tubing string 21, andhas a reduced lower stinger portion 39 which extends downwardly in thebore of the packer and plug tool 30. The operator and running tool alsoincludes a lateral flow pot port sleeve valve 40 having a valve closuremember 41 slidable therein for closing the lateral ports 42 in saidsleeve valve, and holddown means 45a movable laterally thereof by fluidpressure from within the bore of the mandrel of or body of said operatorand running tool. Below the holddown means, the operator means isprovided with a fluid pressure responsive actuator assembly 48 which isoperable in response to fluid pressure from within the bore of themandrel to engage and move the sealing means and gripping members orslips of the packer and bridge plug to expanded gripping positionengaging the bore wall of the casing, whereby the sealing means andgripping means of the packer an and bridge plug are expandedhydraulically and without mechanical operation or manipulation of thetubing string 21.

The lower portion of the mandrel or body of the packer and plug is alsoprovided with a sliding sleeve valve assembly 50 having lateral portsinitially closed by a thimble closure member or sleeve 51 telescopedover the lower end of the mandrel and closing the lateral ports 52 inthe ported mandrel or body 55 of the sleeve valve assembly. Within thebore of the mandrel is a longitudinally slidable valve closure member 53having lateral ports 54 which are initially in registry with the ports52 in the mandrel or body. This inner sliding sleeve closure member 53is movable longitudinally with respect to the lateral ports to reclosethe ports after the same have been opened by removal the the thimbleclosure member 51 from the lower end of the mandrel, and will behereinafter more fully explained. A releasable connection is providedbetween the lower reduced end or stinger 39 of the mandrel 38 of theoperator and running tool and the inner sleeve closure member 53 foractuating the same from opened to closed positions, as will behereinafter more fully explained.

In use in treating or operating a well, the well tubing string 21 havingthe operator and running tool 31 connected to the lower end thereof andcarrying the packer and plug tool 30 therebelow is lowered into the wellbore from the floating or other type platform P to position the packerand plug tool 30 at the desired location in the well bore with respectto the well formation F. The tubing string is then hung by means of thehanger 22 in the wellhead H and the rams 23 of the blowout i preventer Bare closed about the upper end of the tubing string. The flow conduit orconductor T and the lateral flow conductor L are connected to the upperend of the tubing string 21 and to the lateral flow wing 25 of thewellhead, respectively, as shown in FIG. 1, and extend from the wellheadto the platform P. Should any storm or other dangerous condition arise,the flow conduit T and the lateral flow conduit L may be disconnected inthe manner set out and disclosed in the Taylor U.S. Pat Pat. No.3,411,576, whereby it is not necessary that the tubing string and theoperator and running tool and the packer and plug tool be removed fromthe well in the event of the occurrence of such conditions.

In carrying out the process and method of treating the well after thewell installation has been made in the casing, a packer setting bar andplug 60 is pumped or otherwise moved through the tubing string into thebore of the packer and plug tool 30.

The elongate packer setting bar and plug 60 is circulated through thetubing string 21 into the bore of the packer and plug tool until thelarge plug member 62 at the lower end of pumping such as water, into thewell tubing, is directed through the lateral openings 65 in the actuatorassembly 48 of the operator tool into the cylinder 66 to act on thelongitudinally movable actuator piston 66, which has seals 66aengagingthe wall of the cylinder 67 and seals 66bengaging the mandrel 33, tomove the same longitudinally on the mandrel 38 of the operator andrunning tool until the enlarge skirt 68 threaded at 660 on the lower endof the piston engaged and compresses the gripping means 36 and 37 towardeach other and expands the sealing member 35 into sealing engagementwith the bore wall of the well casing. The pin 76a releasably holdingthe upper slip carrying sleeve 76 in an upper retracted position on themandrel is sheared to permit the upper slips 77 to move downwardly onthe upper expander cone 79 and shear the pin 79a holding the cone 79 inits upper position. The seal means 35 is compressed downwardly to shearthe pin 74a holding the lower expander cone 74 in its upper retractedposition, and such lower cone moves downwardly within the lower slips 72to spread the retaining band 73 and expand the lower slips to grippingposition on the supporting flange 71 on the mandrel 33. The seal meansis then fully expandable and the upper slips 77 are expanded to grippingposition spreading the band 78 to permit such expansion. The packer isthus set in gripping sealing position by fluid pressure applied throughthe actuator assembly 48 of the operator and running tool withoutmechanical movement or actuation of the tubing string.

A suitably elevated pressure is then applied by means of the liquid,such as water, in the tubing string and acts on the plug 62 of thepacker setting bar and plug 60 to shear the pins 64 and force thethimble 50 downwardly off the ported valve body 55 at the lower end ofthe mandrel 33 of the packer to open the lateral ports 52 and 54 and tomove the setting bar and plug out of the lower open end of the bore ofthe packer and plug. The enlarged head 61 at the upper end of thesetting bar provides a restriction to fluid flow through the bore of themandrel of the packer and plug and assures that the elongate setting barmoves the thimble off the valve body at the lower end of the mandrel ofthe packer and plug tool.

The packer and plug tool are now in the set gripping and sealingposition shown in FIG. 3; and, with the packer to set, and the tubingfull of fluid, such as water, and the lower open end of the packer andplug open to flow therethrough, the well is in condition to be testedfor production. Fluids may be flowed from the well formation F upwardlythrough the bore of the packer and plug and the operator and runningtool through the tubing string 21 to the surface of the water at theplatform P.

With the packer and plug tool so set in sealing position, the formationis tested for productivity and determination of whether to complete thewell in that formation, or to cement the tested formation and then testanother producing zone. After the completion of the production test, thewell is making no liquids, or if the well formation will take the fluidspresent in the tubing string 21 without damage, it is possible to cementthe well bore below the packer without killing the well by admitting mudor loading fluid from the annulus into the tubing string. In such case,the cement would be pumped downwardly through the packer and plug tooland out the open end thereof to close the well bore therebelow.

If, however, as is the usual case, it is desired to kill the well andthen to introduce cement for plugging, a weighted plug tool is droppedinto the well bore through the conductor and moved downwardly therein bygravity until the plug tool engages the seat 43 at the upper end of theclosure sleeve 41 of the lateral flow sleeve valve 40 in the operatorand running tool. Fluid pressure introduced into the well flow conductorT and tubing 21 above the plug 70 will force the sleeve 41 downwardly toopen the lateral ports 42 for flow therethrough. When it has beendetermined that the sleeve is opened, the loading fluid, or mud or thelike, in the annulus A between the casing and flow tubing string ispermitted to enter through the ports 42 and circulates the plug 70 outof the well tubing back upwardly through the production tubing 21 andconduit T. A column of loading fluid or mud will now be present in thetubing string, and the cement may be introduced in the usual manner intothe well.

A straddle and sealing plug assembly 80 comprising a tubular straddleport closure member 81 and a closure plug assembly 82 releasably securedthereto is inserted into the flow conduit T and pumped downwardly aheadof the cement through the tubing string 21 into the upper end of thebore of the operator and running too] 31, as shown FIGS. 4 and 15. Anexternal annular shoulder 83 on the tubular port closure member 81engaged the seat 43 at the upper end of the Sleeve 41 and limits furtherdownward movement of the tubular straddle port closure. Sealing members840 and 84b on the port closure sleeve 81 seal between the closuresleeve and the bore wall of the mandrel or body 38 of the operator toolabove and below the ports 42 to close off fluid flow through suchlateral ports. An annular upwardly facing sealing cup 88 on the upperend of the straddle closure members assures that fluid pressure willmove the assembly into the well and bore of the operator and runningtool. Further fluid pressure applied to the closure plug assembly 82will shear the pins 85 connecting the plug assembly to the tubular portclosure 81 and cause the closure plug assembly to move downwardlythrough the bore of the operator and running tool and the packer andplug until a stop shoulder 86 on the lower mandrel section 87 of theplug assembly engages the shoulder 56 at the upper end of the flangeforming the lower reduced bore 57 of the ported valve body 55 at thelower end of the mandrel of the packer and plug tool. A split lockingring 58 on the mandrel section 87 is disposed to engage the lower end ofthe mandrel to lock the plug assembly in place in the bore of the body55, and sealing means 59 on the exterior of the mandrel of the plugseals with and closes the bore 57 of the body against flow therethrough.

With theparts in the position shown in FIGS. 5 and 16, eement pumpeddown through the tubing string 21 will flow downwardly through theoperator and running toll 31 and the packer plug assembly and act on thelarge resilient bulbar a seal member 89 to force the stem section 8701'the plug mandrel downwardly after shearing the pin 87b connecting thestem and mandrel, to move the bulbar seal member into the enlarged bore53a of the sliding closure sleeve 53 below the lateral ports 54 and 52.The cement may then flow outwardly through the lateral ports 54 and 52of the sliding sleeve valve assembly at the lower end of the mandrel ofthe packer and plug tool 30, and will enter the formation through theperforations in the casing C or other openings thereto below the packer.Since high pressures are used in cementing, the holddown assemblyprevents upward displacement of the packer and plug tool duringcementing or application of high pressures during other operations. Theelongate toothed gripping members or buttons 450 are normally biasedinwardly to retracted positions in the lateral recesses 45c in themandrel 38 by leaf springs 46 retained in the recesses by retainingrings 46a secured by bolts to the mandrel. Seal supports 47 are securedby bolts to the gripping member members 45a with the walls of the recesswhereby fluid pressure from within the bore of the mandrel actingthrough the lateralapertures 45b forces the gripping members 45aoutwardly to grip the casing wall and prevent upward movement of theoperator and running tool. Metal protective inserts 47b in the sealmember disposed to cover the lateral apertures 45b.prevent extensivedamage to the seal member by external. fluid pressure. An elongatetubular protector sleeve 44 secured to the mandrel 'above the lateralapertures and extending substantially below the lowermost apertureprovides an annular chamber or receptacle 440 into which water-pumpgrease or similar material may be disposed to exclude cement sand orother foreign matter form entry into the recesses 45c behind thegripping members 45a, so that such members are assured of beingretractable.

After a suitable quantity of cement has been introduced and a. suitablecementing squeeze pressure has been obtained, the

operator and running tool 31 is lifted by means of the tubing string 21,as shown in FIG. 6, and the lower reduced or stinger portion 39 of themandrel 38 of the operator and running toll lifts the sliding closuresleeve 53 to move the ports 54 therein above the upper seal 56 in thebore of the valve body and to move the imperforate portion of the sleeveopposite the ports 52 in the body and between the seals 56 on oppositesides of the ports 52 to close the lateral ports against flowtherethrough. With the parts 'in this position, all flow past the packerand plug tool is cut off, and the well bore is plugged at and below thepacker and plug.

The releasable connection between the operator and running tool 31 andthe packer and plug tool 30 is released, as the yieldable cylindricalshear sleeve is sheared by the lifting force of the flange 910 on theconnector body 91 of the mandrel 38 acting against the bushing 92threaded into the shear sleeve above the weakened shear section 93 inthe shear sleeve, as shown in FIG. 17, to permit to the operator andrunning tool to move upwardly longitudinally of the packer an and plugtool and away from the same. Such upward movement of the operator andrunning tool moves the reduced lower or stinger portion 39 of theoperator and running too] mandrel 38 upwardly, and the flange 95 at thelower end of the stinger engages the inwardly projecting bosses 96 onthe resilient leaf spring sections 97 formed in the upper portion of thesliding closure sleeve 53 to move the sliding closure sleeve upwardlyuntil the outer bosses 98 on said leaf spring sections enter the annularrecess 99 in the upper portion of the bore of the valve body member 55,and are moved outwardly by the flange into the recess top to permit theflange to pass the inner bosses 96 and the operator and running tool tobe completely disengaged from the sliding closure sleeve sleeve.

The closure sleeve is then in the upper position shown in FIG. 18,closing off the lateral flow ports 54 and 52 of the sliding sleeve valveassembly 50. The plug assembly 82 also closes the bore of the packer andplug tool at the lower end of the body 55, and the straddle closuresleeve 81 closes the lateral ports 42 in the lateral flow ported sleevevalve 40. Any excess cement in the well bore above the packer and plugtool may be then circulated out of the well by pumping downwardlythrough the casing and upwardly through the tubing to remove the same inthe usual manner.

In the event it is desired to establish circulation between thetubing-casing annulus and the bore of the tubing string before theoperator and running tool 31 is disconnected from the packer and plugtool 30, circulation fluid introduced into the annulus will enter theports 42 in the sleeve valve 40 and act on the downwardly facingdifferential area of the straddle closure sleeve 81 defined by the largeupper seals 84a and the smaller lower seals 84b to move the closuresleeve 81 upwardly ad and permit the circulation fluids to enter thebore of the operator and running tool 31 and flow upwardly through thetubing 21.

After the operator and running tool has been disconnected from thepacker and plug tool, the tubing string 21 with the operator and runningtool connected thereto may be pulled out of the well casing andrefitted, leaving the packer and bridge plug tool in place in the well;and, a new packer and plug tool may be connected to the operator andrunning tool for running into the well. The operations of testing andtreatingthe well hereinbefore described may then be repeated, locatingthe packer and plug-tool at a different position in the well andcarrying out the operations and method previously described herein.

The operator of a will usually avoid cementing a formation which intests shows good potential, and understandably so, because to do sowould likely have a seriously detrimental effect upon the formation. Ifsuch is the case, instead of cementing, the operator would merely liftthe flow tubing- 21 to withdraw. the stinger 39 from the packer and plugtool. Such withdrawal moves the valve closure sleeve 53 upwardly intoposition closing the lateral flow ports 52 and leaving the plug tool 81:in place closing the lower end of the bore of the mandrel 33. so thatflow through the bore of the packer and plug tool in either direction isclosed off and the formation just tested is isolated from the well boreabove the packer and plug tool. If desired, production testing ofshallower formations above the packer and plug tool can then be carriedout.

lf it is later desired to produce the formation sealed off below thepacker and plug tool, a tubing string having a body and stinger member,similar to the flanged connector body 91 and the reduced lower extensionor stinger 39 of the operator and running tool 31 with the flange 95 atits lower end, can be lowered into the well to engage and move theclosure sleeve 53 downwardly in the body 55 to open the lateral ports 52to permit the lower formation F to be produced through such ports and upthe tubing string. This stinger would be provided with seals such as theseals 115 on the stinger 39 and the flanged connector body would beprovided with a J-slot instead of the straight slot 111 for engagementwith the .l-lug 110 in the upper end of the bore of the packer and plugtool to latch the stinger in stationary sealing position in the bore ofthe packer and plug tool to direct fluids flowing from the formation Fto the tubing string and the well surface.

Alternatively, the packer and plug tool could be drilled up or destroyedand removed from the well bore by well known techniques, and the wellcompleted in the lower formation in the usual manner for po productionthrough the tubing string. The foregoing description of the invention isexplanatory only, and changes in the details of the constructionsillustrated may be made by those skilled in the art, within the scope ofthe appended claims, without departing from the spirit of the invention.17

lclaim:

1. Well apparatus adapted to be operated in a well bore, including:first and second tubular body means releasably connected in axiallyaligned relationship; normally retracted expansible gripping means andsealing means on said first body means; normally retracted expansibleholddown means on said second body means; means on said second bodymeans for connecting it to a well flow conductor for moving said firstand second body means into said well bore; and fluid pressure responsiveactuator means on said second body means operable to expand saidgripping means and said sealing means on said first body means togripping and sealing engagement with the wall of said well bore; saidsecond body means being disconnectable from said first body means uponlongitudinal movement of said second body means relative to said firstbody means.

2. Well apparatus of the character set forth in claim 1, wherein saidsecond body means has initially closed, openable, and reclosable lateralflow port means provided thereon for communicating the interior of saidsecond body means with the well bore exteriorly of said second bodymeans above said sealing means of said first body means when saidlateral port means is open for establishing circulation of fluidsthrough said flow conductor and said well bore above said sealing means.

3. Well apparatus of the character set forth in claim 1, wherein saidfirst body means has initially closed, openable, and reclosable lateralflow port means providing a fluid passage between the interior of saidfirst body means and the well bore below said sealing means when saidlater said lateral flow means is open.

4. Well apparatus of the character set'forth in claim 3, wherein plugmeans is provided in the bore of the said first body means to close thebore of said first body means below said lateral flow port means of saidfirst body means.

5. Well apparatus of the character set forth in claim 2, wherein closingmeans is provided to reclose the lateral flow port means of said secondbody means after the same has been opened.

6. Well apparatus of the character set forth in claim 1, whereinconnecting means are provided on said first body means and said secondbody means releasably connecting the same, said connecting meansincluding yieldable means constructed to fail when stressed to apredetermined value to effect disconnection of said second body meansfrom said first body means when said second body means is movedlongitudinally relative to said first body means.

7. Well apparatus of the character set forth in claim 4, wherein sleeveport closure means is provided on said first body means movable to closesaid lateral flow port means of said first body means when said secondbody means is disconnected from said first body means.

8. Well apparatus of the character set forth forth in claim 7, means onsaid sleeve port closure means and means on said second body meanscoengageable to move said sleeve port closure means to position closingsaid lateral flow port means of said first body means upon withdrawal ofsaid second body means from said first body means.

9. Well apparatus of the character set forth in claim 7, including:laterally movable connector means carried by said sleeve port closuremeans, said connector means having inner and outer bosses formedthereon; flange means on the lower portion of said second body meansengageable with said inner bosses of said connector means of said sleeveport closure means to move said closure means from open to closedposition', recess means provided in said first body means for receivingsaid outer bosses of said connector means of said sleeve port closuremeans when said closure means is disposed in a position closing saidlateral flow port means of said first body means, whereby said connectormeans may be moved laterally to a position releasing the inner bosses ofsaid connector means from engagement with said flange means of saidsecond body means to permit withdrawal of said second body means fromsaid first body means, leaving said sleeve closure means closing saidlateral flow port means and said plug means closing the bore of saidfirst body means below said sleeve closure means.

10. Well apparatus of the character set forth in claim 1, wherein saidhold down means on said second body means comprises normally retractedgripping means exposed to and expandable by fluid pressure in saidsecond body means into engagement with the inner wall of said well boreto hold said second body means against longitudinal displacement in saidwell bore.

1 1. Well apparatus of the character set forth in claim 10, including:sleeve closure means in said second body means initially closing thelateral flow port means thereof and shiftable to a position opening saidport means; and means for said shifting said sleeve closure means fromto port-closing portopening position, said shifting means beinginsertable into said second body means through said flow conductor toengage said sleeve closure means for moving the same in response tofluid pressure.

12. Well apparatus of the character set forth in claim 11, includingclosure sleeve means for reclosing said lateral flow port means of saidsecond body means after the same has been opened, said closure sleevemeans being insertable into said second body means through said flowconductor.

13. Well apparatus of the character set forth in claim 10, includingyieldable barrier means disposed in said second tubular body meansbetween said hold down means and the bore of said second body means forexcluding actuating fluids, cement, or other foreign matter from directcontact with said hold down means.

14. Well apparatus adapted to be operated in a well bore, including:well packer and plug tool means; operator and running tool means; meansreleasably connecting said well packer and plug tool means and saidoperator and running tool means in axially aligned relationship;normally retracted expansible sealing means on said packer and plugtool; normally retractor expansible gripping means on said packer andplug tool above and below said sealing means; actuator means on saidoperator and running tool engageable with said upper gripping means ofsaid pacer packer and plug tool and operable by fluid pressure to movesaid gripping means and said sealing means of said packer and plug toolto gripping and from a wellhead at the upper end of the well bore; andmeans insertable into said packer and plug tool-for plugging the same;said means releasably connecting said operator and running tool to saidpacker and plug'tool being releasable upon longitudinal movement of saidoperator and running tool relative to said packer and'plug tool aftersaid packer and plug 7 tool is anchored in sealing position in said welland plugged.

15. The method of treating a well penetrating an earth for mation,comprising the steps of: lowering a pressure actuatable tubular holddownand setting tool and tubular setting'tool and tubular packer and plugwell tool releasably connected to said holddown and setting tool intothe well on a flow conductor to a location above the earthy formation tobe treated; suspendingthe flow conductor at the upper end of the well;pressurizing said flow conductor to actuate said holddown and settingtool to hold the lower end of the flow conductor against movement insaid well andto move said packer and plug well tool to anchored sealingposition between said flow conductor and the bore of said well; testingsaid earth formation by flowing fluids from said formation through saidwell tool and said flow conductor to the surface.

16. The method of claim 15, including the additional steps of:establishing a fluid passageway between the bore of said flow conductorand the well bore above said well tool; and circulating fluid throughsaid well bore above said well tool, through said fluid passageway andthrough saidflow conductor to kill said well. I

17. The method of claim 16, including the additional steps of: closingsaid fluid passageway between said flow conductor and said well bore;and forcing cement through said flow conductor and said well tool toplug said well bore below said well tool.

18. The method of claim 17, including the additional steps of: pluggingthe bore of said well tool; disconnecting said holddown and setting toolfrom said well tool; and removing said flow conductor and holddown andsetting tool from said well.

19. The method of claim 17, including the additional steps of: pluggingthe bore of said well tool; disconnecting said holddown and setting toolfrom said weld tool, circulating control fluid through said well boreand SAlD flow conductor above said well tool to remove unused cementfrom said well; and removing said flow conductor and said holddown andsetting tool from said well.

20. The method of claim 15, including the additional steps of:establishing a fluid passageway between the bore of said holddown andsetting tool and the well bore above said packer and plug well tool;injecting cement into the upper end of said flow conductor to displacethe contents of the flow conductor through said fluid passageway intothe well bore above said well tool; closing said fluid passageway;forcing a portion of said cement through said well tool into the wellbore below said well tool to plug the well bore below said well tool;reopening said fluid passageway; injecting fluid into the upper end ofthe well bore exteriorly of the flow conductor and through said fluidpassageway to displace the unused cement in the flow conductor to thesurface.

21. The method of claim 20, including the additional steps of: pluggingthe bore of said well tool; disconnecting said holdv down and settingtool from said well tool; and removingsaid flow conductor and andsetting tool from said well.

22. Them The method of claim 15, including the additional steps of:establishing a fluid a passageway between the bore of said holddown andsetting tool and the well bore above said well tool; injecting apredetermined amount of cement into the upper end ofsaid flow conductor.to displace the contents of said flow conductor through said fluidpassageway into the wellbore above said well toolclosingl said fluidpassageway; forcing fluid into the upper end of the ow conductor forforcing said cement through said well tool into said earth formationuntil a desired predetermined squeeze pressure is reached; maintainingsaid squeeze pressure plugging the well bore atsaid well tool; anddisconnecting said holddown and setting tool from said well tool and.removing said flow conductor and holddown and to setting tool from saidwell, leaving said well tool in said well bore.

23. The method of claim 15, including the additional steps of:establishing a fluid passageway between the bore of said holddown andsetting tool and the well bore above said well tool; forcing fluid intothe upper end of said well bore exteriorly of said flow conductor andthrough said fluid passageway to displace the contents of said well boreabove said well tool into said flow conductor to the upper end of saidflow conductor; injecting cement into the upper end of the flowconductor to displace the contents of said flow conductor through saidpassageway and into the well bore above said well tool; closing saidfluid passageway; forcing fluid'into the upper end of said flowconductor and forcing cement throughsaid well tool into said earthformation until a desired predetermined squeeze pressure is reached;maintaining said Qsqueeze pressure; plugging said well bore at said welltool; disconnecting said holddown and setting tool from said well tool;and removing said flow conductor and holddown and setting tool from saidwell, leaving said welltool in place in said well bore to plug the same.i

24. In the method of claim 22, the step of: circulating fluid down saidwell bore exteriorly of said flow conductor into the lower end of saidholddown and setting tool and up through said flow conductor to removeunused cement from the well after disconnecting said holddown andsetting tool from said well tool and before removing said flow conductorand holddown and setting tool from said well.

25. In the method of claim 23, the step of of: circulating fluid downsaid well bore exteriorly of said flow conductor into the lower end ofsaid holddowrn andsetting tool and up through said flow'conductor toremove unused cement from the well, after disconnecting said holddownand setting tool from said well tool and before removing said flowconductor and holddown and setting tool from said well.

22 2 33 9 UNlTED sT TEs PATENT OFFICE CERTIFICATE OF CORRECTION PatentNo. 3 ,556, 220 Dated January 19 1971 Inve or) Harry E. Schwegman It iscertified that error appears in the above-identified patent and thatsaid Letters Patent are hereby corrected as shown below:

Column 1, line 5, omit "it to" Column 1 line 44 omit "of" Column 1 line52, after "off insert --said well formation; a

wherein said operator means and- Column 1 line 66 omit "thru"; sameline, after "through" insert --said-- Column 2 line 9, for "vie" read--viewsame line omit "sh Column 2 line 24 omit "showing the well tool" DColumn 2 line 52, for "he" read --the- Column 2 line 66 omit "to" Column2 line 70 after "this" insert -invention- Column 3, line 8 omit "pot"Column 3, line 10, after "means" insert --45 having fluid pres expansib1e gripping means or buttons-- Column 3, line 12, omit "of" (firstoccurrence) Column 3, line 20, omit "an" Column 3, line 34 for "the"(first occurrence) read -of- Column 3, line 58, omit "Pat" (firstoccurrence) Column 3, line 70 for "engaged" read --engages-- Column 3,line 74 for "c" read -by- Column 4 line 1 after "pumping" insert -fluid,

Column 4 line 7 for "enlarge" read --en1arged Column 4 line 8, for"engaged" read --engages-- Column 4, line 42, for "to" read -so- Column4, line 55 after the comma insert --if- Column 5 line 12 for "engaged"read --engages-- Column 5 line 38 for "toll" read --tool- Column 5, line39, omit "a" Column 5, line 58 omit "member"; same line after "45a"inser --and have fluid pressure seals 47a on their inner side sealing--Column 5 line 71 for "form" read --from-- Column 6, line 3, for "toll"read --tool-- Column 6, line 18 omit "to" (second occurrence) UNITEDSTzilES PATENT OFFICE CERTIFICATE OF CORRECTION Patent No. 3,556 220Dated January 19, 1971 Inventor(s) Harry E. Schwegman It is certifiedthat error appears in the above-identified patent and that said LettersPatent are hereby corrected as shown below:

(continued from Page 1) Column 6, line 19, omit "an" Column 6, line 33,omit "sleeve" (first occurrence) Column 6, line 52, omit "ad" Column 6,line 67, before "will" insert --well-- Column 7, line 26, omit "po"Column 7, line 27, begin new paragraph Column 7, line 31, omit "17"Column 7, line 62, omit "said later" Column 7, line 63, after "flow"insert --port-- Column 7, line 65, omit "the" (second occurrence) Column8, line 10, after "claim 7," insert --including-- Column 8, line 47,omit "said" (second occurrence) Column 8, line 48, omit "to"; same line,after "port-closing insert --to- Column 8, line 70, for "retractor" read--retracted-- Column 8 line 73, omit "pacer" Column 9, line 16, omit"tubular setting tool" Column 9, line 17, omit "and" (first occurrence)and insert Column 9, line 46, for "weld" read -'-well-- Column 9, line47, for "SAID" read -said- Column 10, line 10, omit "Them" Column 10,line 11, omit "a" (second occurrence) Column 10, line 20, after"pressure" insert a semicolon Column 10, line 23, omit "to" Column 10,line 34, before "passageway" insert --fluid- Column 10, line 51, omit"of" (second occurrence) Signed and sealed thiS lBth day of May 1971.

(SEAL) Attest:

EDWARD M FLETCHER JR. a El SCH YLER, Attesting Officer Commissioner 0Pate

1. Well apparatus adapted to be operated in a well bore, including:first and second tubular body means releasably connected in axiallyaligned relationship; normally retracted expansible gripping means andsealing means on said first body means; normally retracted expansibleholddown means on said second body means; means on said second bodymeans for connecting it to a well flow conductor for moving said firstand second body means into said well bore; and fluid pressure responsiveactuator means on said second body means operable to expand saidgripping means and said sealing means on said first body means togripping and sealing engagement with the wall of said well bore; saidsecond body means being disconnectable from said first body means uponlongitudinal movement of said second body means relative to said firstbody means.
 2. Well apparatus of the character set forth in claim 1,wherein said second body means has initially closed, openable, andreclosable lateral flow port means provided thereon for communicatingthe interior of said second body means with the well bore exteriorly ofsaid second body means above said sealing means of said first body meanswhen said lateral port means is open for establishing circulation offluids through said flow conductor and said well bore above said sealingmeans.
 3. Well apparatus of the character set forth in claim 1, whereinsaid first body means has initially closed, openable, and reclosablelateral flow port means providing a fluid passage between the interiorof said first body means and the well bore below said sealing means whensaid later said lateral flow means is open.
 4. Well apparatus of thecharacter set forth in claim 3, wherein plug means is provided in thebore of the said first body means to close the bore of said first bodymeans below said lateral flow port means of said first body means. 5.Well apparatus of the character set forth in claim 2, wherein closingmeans is provided to reclose the lateral flow port means of said secondbody means after the same has been opened.
 6. Well apparatus of thecharacter set forth in claim 1, wherein connecting means are provided onsaid first body means and said second body means releasably connectingthe same, said connecting means including yieldable means constructed tofail when stressed to a predetermined value to effect disconnection ofsaid second body means from said first body means when said second bodymeans is moved longitudinally relative to said first body means.
 7. Wellapparatus of the character set forth in claim 4, wherein sleeve portclosure means is provided on said first body means movable to close saidlateral flow port means of said first body means when said second bodymeans is disconnected from said first body means.
 8. Well apparatus ofthe character set forth forth in claim 7, means on said sleeve portclosure means and means on said second body means coengageable to movesaid sleeve port closure means to position closing said lateral flowport means of said first body means upon withdrawal of said second bodymeans from said first body means.
 9. Well apparatus of the character setforth in claim 7, including: laterally movable connector means carriedby said sleeve port closure means, said connector means having inner andouter bosses formed thereon; flange means on the lowEr portion of saidsecond body means engageable with said inner bosses of said connectormeans of said sleeve port closure means to move said closure means fromopen to closed position; recess means provided in said first body meansfor receiving said outer bosses of said connector means of said sleeveport closure means when said closure means is disposed in a positionclosing said lateral flow port means of said first body means, wherebysaid connector means may be moved laterally to a position releasing theinner bosses of said connector means from engagement with said flangemeans of said second body means to permit withdrawal of said second bodymeans from said first body means, leaving said sleeve closure meansclosing said lateral flow port means and said plug means closing thebore of said first body means below said sleeve closure means.
 10. Wellapparatus of the character set forth in claim 1, wherein said hold downmeans on said second body means comprises normally retracted grippingmeans exposed to and expandable by fluid pressure in said second bodymeans into engagement with the inner wall of said well bore to hold saidsecond body means against longitudinal displacement in said well bore.11. Well apparatus of the character set forth in claim 10, including:sleeve closure means in said second body means initially closing thelateral flow port means thereof and shiftable to a position opening saidport means; and means for said shifting said sleeve closure means fromto port-closing port-opening position, said shifting means beinginsertable into said second body means through said flow conductor toengage said sleeve closure means for moving the same in response tofluid pressure.
 12. Well apparatus of the character set forth in claim11, including closure sleeve means for reclosing said lateral flow portmeans of said second body means after the same has been opened, saidclosure sleeve means being insertable into said second body meansthrough said flow conductor.
 13. Well apparatus of the character setforth in claim 10, including yieldable barrier means disposed in saidsecond tubular body means between said hold down means and the bore ofsaid second body means for excluding actuating fluids, cement, or otherforeign matter from direct contact with said hold down means.
 14. Wellapparatus adapted to be operated in a well bore, including: well packerand plug tool means; operator and running tool means; means releasablyconnecting said well packer and plug tool means and said operator andrunning tool means in axially aligned relationship; normally retractedexpansible sealing means on said packer and plug tool; normallyretractor expansible gripping means on said packer and plug tool aboveand below said sealing means; actuator means on said operator andrunning tool engageable with said upper gripping means of said pacerpacker and plug tool and operable by fluid pressure to move saidgripping means and said sealing means of said packer and plug tool togripping and sealing position; normally retracted fluid pressureexpansible hold down means on said operator and running tool; lateralflow port sleeve valve means on said operator and running tool abovesaid packer and plug tool; flow conductor means connected to the upperend of said operator and running tool; hanger means on said flowconductor for suspending the same from a wellhead at the upper end ofthe well bore; and means insertable into said packer and plug tool forplugging the same; said means releasably connecting said operator andrunning tool to said packer and plug tool being releasable uponlongitudinal movement of said operator and running tool relative to saidpacker and plug tool after said packer and plug tool is anchored insealing position in said well and plugged.
 15. The method of treating awell penetrating an earth formation, comprising the steps of: lowering apressure actuatable tubular holddown and setting tool and tubularsetting tool and tubUlar packer and plug well tool releasably connectedto said holddown and setting tool into the well on a flow conductor to alocation above the earth formation to be treated; suspending the flowconductor at the upper end of the well; pressurizing said flow conductorto actuate said holddown and setting tool to hold the lower end of theflow conductor against movement in said well and to move said packer andplug well tool to anchored sealing position between said flow conductorand the bore of said well; testing said earth formation by flowingfluids from said formation through said well tool and said flowconductor to the surface.
 16. The method of claim 15, including theadditional steps of: establishing a fluid passageway between the bore ofsaid flow conductor and the well bore above said well tool; andcirculating fluid through said well bore above said well tool, throughsaid fluid passageway and through said flow conductor to kill said well.17. The method of claim 16, including the additional steps of: closingsaid fluid passageway between said flow conductor and said well bore;and forcing cement through said flow conductor and said well tool toplug said well bore below said well tool.
 18. The method of claim 17,including the additional steps of: plugging the bore of said well tool;disconnecting said holddown and setting tool from said well tool; andremoving said flow conductor and holddown and setting tool from saidwell.
 19. The method of claim 17, including the additional steps of:plugging the bore of said well tool; disconnecting said holddown andsetting tool from said weld tool, circulating control fluid through saidwell bore and SAID flow conductor above said well tool to remove unusedcement from said well; and removing said flow conductor and saidholddown and setting tool from said well.
 20. The method of claim 15,including the additional steps of: establishing a fluid passagewaybetween the bore of said holddown and setting tool and the well boreabove said packer and plug well tool; injecting cement into the upperend of said flow conductor to displace the contents of the flowconductor through said fluid passageway into the well bore above saidwell tool; closing said fluid passageway; forcing a portion of saidcement through said well tool into the well bore below said well tool toplug the well bore below said well tool; reopening said fluidpassageway; injecting fluid into the upper end of the well boreexteriorly of the flow conductor and through said fluid passageway todisplace the unused cement in the flow conductor to the surface.
 21. Themethod of claim 20, including the additional steps of: plugging the boreof said well tool; disconnecting said holddown and setting tool fromsaid well tool; and removing said flow conductor and and setting toolfrom said well.
 22. Them The method of claim 15, including theadditional steps of: establishing a fluid a passageway between the boreof said holddown and setting tool and the well bore above said welltool; injecting a predetermined amount of cement into the upper end ofsaid flow conductor to displace the contents of said flow conductorthrough said fluid passageway into the well bore above said well tool;closing said fluid passageway; forcing fluid into the upper end of theflow conductor for forcing said cement through said well tool into saidearth formation until a desired predetermined squeeze pressure isreached; maintaining said squeeze pressure plugging the well bore atsaid well tool; and disconnecting said holddown and setting tool fromsaid well tool and removing said flow conductor and holddown and tosetting tool from said well, leaving said well tool in said well bore.23. The method of claim 15, including the additional steps of:establishing a fluid passageway between the bore of said holddown andsetting tool and the well bore above said well tool; forcing fluid intothe upper end of said well bore exteriorly of said flow conductor andthrough saId fluid passageway to displace the contents of said well boreabove said well tool into said flow conductor to the upper end of saidflow conductor; injecting cement into the upper end of the flowconductor to displace the contents of said flow conductor through saidpassageway and into the well bore above said well tool; closing saidfluid passageway; forcing fluid into the upper end of said flowconductor and forcing cement through said well tool into said earthformation until a desired predetermined squeeze pressure is reached;maintaining said squeeze pressure; plugging said well bore at said welltool; disconnecting said holddown and setting tool from said well tool;and removing said flow conductor and holddown and setting tool from saidwell, leaving said well tool in place in said well bore to plug thesame.
 24. In the method of claim 22, the step of: circulating fluid downsaid well bore exteriorly of said flow conductor into the lower end ofsaid holddown and setting tool and up through said flow conductor toremove unused cement from the well after disconnecting said holddown andsetting tool from said well tool and before removing said flow conductorand holddown and setting tool from said well.
 25. In the method of claim23, the step of of: circulating fluid down said well bore exteriorly ofsaid flow conductor into the lower end of said holddown and setting tooland up through said flow conductor to remove unused cement from thewell, after disconnecting said holddown and setting tool from said welltool and before removing said flow conductor and holddown and settingtool from said well.